CN-122016566-A - Dynamic phase permeation simulation method and product for influencing wettability by fluid components

Abstract

The application provides a dynamic phase permeation simulation method and a product for influencing wettability by fluid components, wherein the method comprises the steps of simulating a fluid displacement process of a core sample based on a digital core model of the core sample; the digital core model is used for representing the distribution condition of pores and minerals in a core sample, determining the wetting contact angle of the target minerals based on surface complexation characteristic parameters of the target minerals and chemical environment parameters of target fluids contacted by the target minerals in the fluid displacement process, wherein the target minerals are minerals contacted with the target fluids in a plurality of minerals adjacent to the pores, and determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample. According to the method, the relative permeability of the core sample is determined by using the wetting contact angle determined based on the mineral surface complexing characteristic parameter and the fluid chemical environment parameter in a mode of simulating fluid displacement based on the digital core model of the core sample, so that the accuracy of determining the core permeability can be improved.

Inventors

• LONG WEI
• XIONG ZHAO
• WANG GUANQUN
• LI WEI

Assignees

• 清能艾科（深圳）能源技术有限公司

Dates

Publication Date

20260512

Application Date

20260127

Claims (10)

1. 1. A method of dynamic phase penetration simulation of a fluid composition affecting wettability, comprising: Simulating a fluid displacement process of a core sample based on a digital core model of the core sample, wherein the digital core model is used for representing the distribution condition of pores and minerals in the core sample; Determining a wetting contact angle of a target mineral based on a surface complexing characteristic parameter of the target mineral and a chemical environment parameter of a target fluid contacted by the target mineral in the fluid displacement process, wherein the target mineral is a mineral contacted with the target fluid in a plurality of minerals adjacent to the pores; and determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
2. 2. The method of claim 1, wherein the fluid displacement process comprises a plurality of time steps; The determining the wetting contact angle of the target mineral based on the surface complexation characteristic parameter of the target mineral and the chemical environment parameter of the target fluid contacted by the target mineral comprises the following steps: determining, for each of the time steps, a target mineral at the time step based on fluid distribution information of the pores at the time step; And determining the wetting contact angle of the target mineral in the time step based on the surface complexing characteristic parameter of the target mineral in the time step and the target chemical environment parameter, wherein the target chemical environment parameter is the chemical environment parameter of the target fluid contacted by the target mineral in the time step.
3. 3. The method of claim 2, wherein determining the wetting contact angle of the target mineral at the time step based on the surface complexation characteristic parameter of the target mineral at the time step and the target chemical environment parameter comprises: Determining the surface charge density of the target mineral in the time step based on the surface complexation characteristic parameter of the target mineral in the time step and the target chemical environment parameter; Determining the wetting contact angle of the target mineral at the time step based on the surface charge density of the target mineral at the time step.
4. 4. The method of claim 2, wherein the plurality of time steps includes a first time step and a second time step, the second time step being a next time step to the first time step, the method further comprising: determining fluid distribution information of the pores at the beginning of the second time step and chemical environment parameters of a target fluid contacted by a target mineral at the beginning of the second time step based on fluid field data of the core sample at the end of the first time step.
5. 5. The method of claim 1, wherein the determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample comprises: Performing fluid dynamics calculation by taking fluid field data of the core sample at the end of a first time step as an initial condition and the wetting contact angle of each target mineral at the end of the first time step as a boundary condition to obtain fluid field data of the core sample at the end of a second time step; Based on the fluid field data of the core sample at the end of the second time step, a relative permeability of the core sample at the end of the second time step is determined.
6. 6. The method of claim 1, further comprising, prior to simulating the fluid displacement process of the core sample based on the digital core model of the core sample: acquiring three-dimensional gray image data bodies and two-dimensional mineral composition data of the core sample; performing multi-mode data fusion and registration on the three-dimensional gray image data body and the two-dimensional mineral composition data to obtain a corresponding relation between a gray value of the core sample and a mineral phase; And dividing the three-dimensional gray image data body based on the corresponding relation between the gray value of the core sample and the mineral phase to obtain the digital core model.
7. 7. A dynamic phase permeation simulation device for influencing wettability by fluid components, which is characterized by comprising a simulation module, a first determination module and a second determination module; The simulation module is used for simulating the fluid displacement process of the core sample based on a digital core model of the core sample, wherein the digital core model is used for representing the distribution condition of pores and minerals in the core sample; The first determining module is used for determining a wetting contact angle of a target mineral based on a surface complexing characteristic parameter of the target mineral and a chemical environment parameter of a target fluid contacted by the target mineral in the fluid displacement process, wherein the target mineral is a mineral contacting the target fluid in a plurality of minerals adjacent to the pores; the second determining module is used for determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample.
8. 8. An electronic device comprising a memory storing a computer program and a processor implementing the method of any of claims 1 to 6 when the computer program is executed by the processor.
9. 9. A computer readable storage medium storing a computer program, characterized in that the computer program when executed by a processor implements the method according to any one of claims 1 to 6.
10. 10. A computer program product, characterized in that the computer program product is stored in a computer-readable storage medium, which computer program product, when being executed by a processor, implements the method according to any of claims 1 to 6.

Description

Dynamic phase permeation simulation method and product for influencing wettability by fluid components Technical Field The application relates to the technical field of petroleum, in particular to a dynamic phase permeation simulation method and a product for influencing wettability by fluid components. Background The relative permeability is a core parameter describing the flow capacity of multiphase fluids such as oil, gas, water and the like in a porous medium of a reservoir, and has decisive effect on reservoir productivity prediction, recovery ratio estimation and development scheme optimization. Inaccurate relative permeability can lead to significant deviations in reservoir numerical simulation results from actual production dynamics. The relative permeability of the core is currently determined mostly through physical displacement experiments. However, in the physical displacement experiment process, the original wetting state of the core is irreversibly damaged due to the treatments such as cleaning and drying, in addition, the wettability of the core is defaulted to be a constant parameter throughout the whole experiment process in the physical displacement experiment, so that the real working condition of the reservoir is completely ignored, and the accuracy of determining the permeability of the core is poor. Disclosure of Invention The embodiment of the application mainly aims to provide a dynamic phase permeability simulation method and a product for influencing wettability by fluid components, and aims to improve accuracy of determining core permeability. The embodiment of the application provides a dynamic phase permeation simulation method for influencing wettability by fluid components, which comprises simulating a fluid displacement process of a core sample based on a digital core model of the core sample, wherein the digital core model is used for representing distribution conditions of pores and minerals in the core sample, determining a wetting contact angle of a target mineral based on a surface complexing characteristic parameter of the target mineral and a chemical environment parameter of the target fluid contacted by the target mineral in the fluid displacement process, wherein the target mineral is a mineral contacted with the target fluid in a plurality of minerals adjacent to the pores, and determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample. In one embodiment, the fluid displacement process comprises a plurality of time steps, wherein the determining of the wetting contact angle of the target mineral based on the surface complexing characteristic parameter of the target mineral and the chemical environment parameter of the target fluid contacted by the target mineral comprises determining the target mineral in the time steps based on the fluid distribution information of the pores in the time steps for each time step, determining the wetting contact angle of the target mineral in the time steps based on the surface complexing characteristic parameter of the target mineral in the time steps and the target chemical environment parameter, and the target chemical environment parameter is the chemical environment parameter of the target fluid contacted by the target mineral in the time steps. In one embodiment, the determining the wetting contact angle of the target mineral in the time step based on the surface complexation characteristic parameter of the target mineral in the time step and the target chemical environment parameter comprises determining the surface charge density of the target mineral in the time step based on the surface complexation characteristic parameter of the target mineral in the time step and the target chemical environment parameter; Determining the wetting contact angle of the target mineral at the time step based on the surface charge density of the target mineral at the time step. In one embodiment, the plurality of time steps includes a first time step and a second time step, the second time step being a next time step to the first time step, the method further comprising determining fluid distribution information for the pores at the beginning of the second time step and chemical environmental parameters for a target fluid contacted by a target mineral at the beginning of the second time step based on fluid field data for the core sample at the end of the first time step. In one embodiment, the determining the relative permeability of the core sample based on the wetting contact angle of each target mineral in the core sample includes performing a hydrodynamic calculation with the fluid field data of the core sample at the end of a first time step as an initial condition and the wetting contact angle of each target mineral at the end of the first time step as a boundary condition to obtain the fluid field data of the core sample at the end of a second time step, and det